Drilling rig having rig operation loads supported on pressure control equipment

ABSTRACT

Generally, the present disclosure is directed to systems and methods for using the pressure control equipment positioned at a wellbore location to support loads generated during rig operations. One illustrative system disclosed herein includes at least one first pressure control device positioned proximate a first wellbore location, the at least one first pressure control device being adapted to retain wellbore pressure at the first wellbore location. The system also includes a first machine positioned proximate the at least one first pressure control device, the first machine being adapted to perform a first rig operation on the first wellbore location. Furthermore, the disclosed system includes a first structural support that is adapted to transfer loads generated by the first machine during the first rig operation to the at least one first pressure control device, wherein the at least one first pressure control device is adapted to support the loads.

CROSS-REFERENCE TO RELATED APPLICATION

This application is a continuation of U.S. application Ser. No.12/634,930, filed Dec. 10, 2009, which was a continuation-in-part ofU.S. application Ser. No. 12/316,801, filed Dec. 15, 2008, which in turnclaims priority to U.S. application Ser. No. 61/189,146, filed Aug. 15,2008.

BACKGROUND OF THE INVENTION

1. Field of the Invention

The present disclosure is directed to drilling oil, gas, and waterwellbores in the earth; in certain particular aspects, to drilling,completing, and/or performing workover operations on such multiplewellbores from a single drilling rig; and, in certain particularaspects, to drilling, completing, and/or performing workover operationson such multiple wellbores so that they can be operated onsimultaneously and/or are relatively close to each other.

2. Description of the Related Art

A wide variety of drilling rigs and methods are known for drilling oil,gas, and water wellbores in subsurface formations. In many known systemsand methods, a single wellbore is drilled with a drilling rig and then,to drill another wellbore, the drilling rig is moved to a new location,often near the drilled wellbore.

Many patents and publications illustrate and describe conventionaldrilling rigs. For example, U.S. Pat. No. 7,320,374 proposes systems andmethods as shown in FIGS. 1A and 1B in which a known top drive systemTDS1 in a derrick 140 is suspended from a block becket 18 which issuspended from the derrick 140 in a typical manner. A standard block andhook for hooking a standard becket may be used. An elevator 74 supportsa tubular stand 142 which includes two pieces (or three) of drill pipe143. The stand 142 has been moved from a monkey board 145 with multiplemade-up stands 149 to a position axially aligned with a wellbore 147. Amouse hole 144 may be used, e.g., to make stands. A driller controlsdrilling from a driller's panel 141. The stands 149 are located at asetback position ST. Optionally, the system includes an emergency brakesystem and/or an emergency shut down device and, optionally, either orboth are controllable from the panel 141.

Also, by way of example only, as shown in FIG. 2, U.S. Pat. No.5,107,940 proposes a known system TDS2 which includes a power swivel 30and guide mechanism 51 mounted on a mast 102 of a conventional portablerotary earth drilling rig generally designated by the numeral 100. Aswill hereinafter be more fully explained, the power swivel 30 ispivotally secured through a floating torque arm assembly, called acarriage 70, to a pair of dollies 75 movable longitudinally on a guidetrack 51 mounted on the mast 102. The guide mechanism 51, illustrated inFIGS. 7-9, and the carriage 70, illustrated in FIGS. 10 and 11 of thedrawings in the '940 patent, form a torque restraint system.

The drilling rig 100 is a conventional 118 foot vehicle-mountedhydraulically telescoping derrick, having an inclined mast 102 with ahook load capacity of, for example, 365,000 pounds. The mast 102 istypically inclined at a lean angle 119 of 3½ degrees relative to avertical axis 125 centered over the well.

The mast 102 is pivotally mounted on a trailer 104 and is transported ina horizontal position with the upper mast section 115 telescoped intothe lower mast section 110. When the mast 102 is erected, the telescopedsections 110 and 115 are rotated approximately 90 degrees about ahorizontal axis to a vertical position by hydraulically-actuated rams106. After legs on the lower mast section 110 engage the ground or othersupporting surface, hydraulic fluid is delivered tohydraulically-actuated cylinders which raise the upper mast section 115to the position illustrated in FIG. 1, wherein only the lower end of theupper section 115 extends downwardly into the upper end of the lowersection 110.

The trailer-mounted rig includes a single drum drawworks 105 powered bydiesel engines 103 through conventional transmissions and a compoundbox. A fast line 107 extends from drawworks 105 upwardly over a crownblock 108, as illustrated in FIG. 2, to provide a number of lines 109which carry a traveling block 112 connected to the power swivel 30 inthe top drive system 20. A conventional folding substructure 140,equipped with a V-door 142, a catwalk 145, and two sets of pipe racks(not shown), parallel and juxtaposed to the catwalk, are mountedadjacent to the inclined telescoping mast 102.

The stand assembly system consists of a crown cantilevered single jointelevator snatch block 21 mounted directly over the mouse hole, anauxiliary cable 22, a live swivel assembly 23 and a single jointelevator 148. The system is permanently installed in the rig for use atany time.

The auxiliary cable 22 is designed to quickly attach to existinghydraulic or pneumatically-powered auxiliary tugger lines and is used tohoist a single joint 24′ from the pipe ramp to the mouse hole, and tohoist a complete stand 25 from the mouse hole to the fingerboard 136 andset the stand 25 back on the setback SK.

The single joint elevator 148 is a specially-designed elevator with, forexample, a 2,000 pound hoisting capacity for quick attachment to andrelease from the drill pipe. It is attached to the auxiliary cable 22utilizing a live swivel assembly 23 to prevent upspiraling of the cablewhile shouldering up a stand 25 in the mouse hole. During operation, astand 25 is attached to or removed from the drill string 150, utilizingelevator 48.

The guide track 51 is rigid and continuous; it extends longitudinallyalong mast 102. The guide track 51 is formed in at least two segments: alower guide track segment 52, and an upper guide track segment 54,secured to the lower mast segment 110 and upper mast segment 115,respectively (see FIG. 1). The guide track 51 shown can be comprised of,for example, 3½ inch standard pipe sections, each approximately 20 feetlong (for easy handling). However, it should be appreciated that guidetrack 51 may be formed of members having non-circular cross-sections,such as H-beams, without departing from the basic concept of the torquerestraint system.

FIGS. 13-15 of U.S. Pat. No. 5,107,940 describe the procedure for makingup a stand 25. FIGS. 16-18 of U.S. Pat. No. 5,107,940 describe how amade-up stand is added to a drilling string.

U.S. Pat. No. 4,108,255 proposes an apparatus for drilling concurrentlya plurality of wells within a laterally confined area. The confines ofthe drilling apparatus employ a structure having vertically extendingwalls rising from a drilling floor. A plurality of wells are drilled,each employing a separate rotary drilling table and a separate draw workassembly mounted in vertical displacement from the drilling tableassociated therewith. The individual draw work assemblies associatedwith separate rotary drilling tables are utilized only to feed drillingpipe assemblies into the well and to aid in the actual drillingoperation. To withdraw drilling pipe assemblies, a master draw works isprovided and is mounted vertically above the draw work assembliesassociated with particular rotary drilling tables. In addition, the drawwork assemblies are preferably located on bridges which are rotatablymounted with respect to an upright central support, so that the bridgesare rotatable about the upright support and carriages forming part ofthe draw works are movable along the bridges so that the carriages maybe moved both radially and rotationally relative to the upright support.The confining structure of the vertically extending walls renders thewell drilling apparatus suitable for construction for use in drillingwells on the floor of a body of water and also for use in drilling aplurality of wells in highly urbanized areas. This versatility isachieved by constructing the well drilling apparatus with exterior wallsof the confining structure in the form of a facade, to resemble acommercial building or in the form of a water resistant caisson that maybe lowered into a body of water to extend from the floor to the surfacethereof. This patent proposes a well drilling apparatus located within aconfining structure having cylindrical annular vertically extendingwalls rising from a drilling floor and enclosing a plurality of rotarydrilling tables laterally displaced from each other proximate to thedrilling floor and within the confines of the walls each arranged toaccommodate separate drilling assemblies including drilling pipe fordrilling separate wells at spatially separated locations at the drillingfloor. Separate drilling draw work assemblies are mounted in verticaldisplacement from each of the rotary drilling tables for manipulatingthe drilling pipe and other portions of the drilling assembly utilizedwith the associated rotary table. Each of the separate drilling drawwork assemblies is mounted on a separate bridge that extends laterallyfrom an upright support and is supported at the vertically extendingwalls at a distance above the rotary drilling table with which it isassociated.

It is often desirable to drill wellbores for hydrocarbon and water wellsrelatively near to each other, e.g., within 8 to 12 feet of each other(or more) in the case of land drilling, and often within 16 to 32 feetof each other (more or less) in the case of offshore/platform drilling.A variety of problems and disadvantages are associated with conventionalways for drilling wellbores that are close to each other. Often, usingrigs designed for drilling one hole and then moving the rig to drillanother hole, much of the total time expended to drill multiple holes isnot time spent actually drilling.

The present disclosure is directed to various methods and devices thatmay avoid, or at least reduce, the effects of one or more of theproblems identified above.

SUMMARY OF THE INVENTION

The following presents a simplified summary of the invention in order toprovide a basic understanding of some aspects of the invention. Thissummary is not an exhaustive overview of the invention, and is notintended to identify key or critical elements of the invention or todelineate the scope of the invention. Its sole purpose is to presentsome concepts in a simplified form as a prelude to the more detaileddescription that is discussed later.

Generally, the present disclosure is directed to systems and methods forusing the pressure control equipment positioned at a wellbore locationto support loads generated during rig operations. One illustrativesystem disclosed herein includes at least one first pressure controldevice positioned proximate a first wellbore location, the at least onefirst pressure control device being adapted to retain wellbore pressureat the first wellbore location. The system also includes a first machinepositioned proximate the at least one first pressure control device, thefirst machine being adapted to perform a first rig operation on thefirst wellbore location. Furthermore, the disclosed system includes afirst structural support that is adapted to transfer loads generated bythe first machine during the first rig operation to the at least onefirst pressure control device, wherein the at least one first pressurecontrol device is adapted to support the loads.

A further illustrative system of the present disclosure includes atleast one pressure control device positioned proximate a wellborelocation, the at least one pressure control device being adapted toretain wellbore pressure at the wellbore location, and a frame structuresupported by the at least one pressure control device. The illustrativesystem further includes, among other things, a drilling machinepositioned proximate the wellbore location, wherein the drilling machineis adapted to perform a drilling operation on the wellbore location, andwherein the frame structure is adapted to support drilling loadsgenerated by the drilling machine during the drilling operation.

According to another illustrative embodiment disclosed herein, a methodis disclosed that includes, among other things, positioning at least onepressure control device proximate a wellbore location, positioning amachine proximate the at least one pressure control device, performing arig operation on the wellbore location with the machine, and supportingloads generated by the machine during the rig operation with the atleast one pressure control device.

BRIEF DESCRIPTION OF THE DRAWINGS

The disclosure is understood by reference to the following descriptiontaken in conjunction with the accompanying drawings, in which likereference numerals identify like elements, and in which:

FIG. 1A is a side view of a prior art drilling rig;

FIG. 1B is a top view of the rig of FIG. 1A;

FIG. 2 is a side view of a prior art drilling rig;

FIG. 3 is a perspective view of an illustrative drilling rig fordrilling oil, gas and/or water wells as disclosed herein;

FIG. 4 is a perspective view of an illustrative drilling rig fordrilling oil, gas and/or water wells as disclosed herein;

FIG. 5A is a perspective view of an illustrative drilling rig fordrilling oil, gas and/or water wells as disclosed herein;

FIG. 5B is a side view of the rig of FIG. 5A;

FIG. 5C is an end view of the rig of FIG. 5A;

FIG. 5D is a top view of the rig of FIG. 5A;

FIG. 6A is a perspective view of an illustrative drilling system fordrilling oil, gas and/or water wells as disclosed herein;

FIG. 6B is a top view of the system of FIG. 6A;

FIG. 7A is a top schematic view showing various steps in an illustrativemethod using a rig as disclosed herein;

FIG. 7B is a top schematic view showing a step in the illustrativemethod of FIG. 7A as disclosed herein;

FIG. 8 is a perspective view of an illustrative system as disclosedherein;

FIG. 8A is a cross-section view of the top of an illustrative roadmodule as disclosed herein;

FIG. 9A is a top schematic view showing locations for multiple wellboresto be drilled and completed;

FIG. 9B is a top schematic view of an illustrative drilling system asdisclosed herein for drilling at the locations shown in FIG. 9A;

FIG. 9C is a top schematic view showing illustrative steps in drillingand completing wells at the locations of FIG. 9A as disclosed herein;

FIG. 10 is a top schematic view of an illustrative drilling system asdisclosed herein;

FIG. 11 is a top schematic view of an illustrative drilling system asdisclosed herein;

FIG. 12 is a top schematic view of an illustrative drilling system asdisclosed herein;

FIG. 13 is a top schematic view of an illustrative drilling system asdisclosed herein;

FIG. 14 is a top schematic view of an illustrative drilling system asdisclosed herein;

FIG. 15 is a perspective view of an illustrative system as disclosedherein;

FIG. 15A is a perspective view of an illustrative rig floor and shakerpit of the system of FIG. 15 as disclosed herein;

FIG. 15B a perspective view of driller's cabin on the rig floor of FIG.15A as disclosed herein;

FIG. 15C is a perspective view of an illustrative crane on the rig floorof FIG. 15A as disclosed herein;

FIG. 15D is a perspective view of the illustrative system parts of FIG.15B with an active mud system as disclosed herein;

FIG. 16A is a perspective view showing an illustrative step in theerection of the rig floor of FIG. 15A as disclosed herein;

FIG. 16B is a perspective view showing an illustrative step in theerection of the rig floor of FIG. 15A as disclosed herein;

FIG. 16C is a perspective view showing an illustrative step in theerection of the rig floor of FIG. 15A as disclosed herein;

FIG. 17A is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17B is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17C is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17D is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17E is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17F is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17G is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17H is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17I is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17J is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17K is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17L is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17M is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17N is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17O is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17P is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17Q is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17R is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17R is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 17S is a perspective view showing a step in the illustrative methodusing the system of FIG. 15 as disclosed herein;

FIG. 18 is a perspective view of an illustrative system as disclosedherein;

FIG. 19 is a perspective view of an illustrative system as disclosedherein;

FIG. 20A is a perspective view of an illustrative system as disclosedherein;

FIG. 20B is a perspective view of the system of FIG. 20A;

FIG. 20C is a top view of the system of FIG. 20A;

FIG. 21 is a perspective view of an illustrative system as disclosedherein;

FIG. 21A is a perspective view from the opposite side of the system ofFIG. 21;

FIG. 21B is a perspective view of an illustrative embodiment of thetubular holder of the system of FIG. 21A;

FIG. 21C is a perspective view of the tubular movement apparatus of thesystem of FIG. 21A; and

FIG. 21D is a perspective view of another illustrative embodiment of thetubular holder of the system of FIG. 21A.

While the subject matter disclosed herein is susceptible to variousmodifications and alternative forms, specific embodiments thereof havebeen shown by way of example in the drawings and are herein described indetail. It should be understood, however, that the description herein ofspecific embodiments is not intended to limit the invention to theparticular forms disclosed, but on the contrary, the intention is tocover all modifications, equivalents, and alternatives falling withinthe spirit and scope of the invention as defined by the appended claims.

DETAILED DESCRIPTION

The present invention includes features and advantages which arebelieved to enable the advancement of oil, gas and water wellboredrilling, completion, and/or workover operations. Various illustrativeembodiments of the invention are described below. In the interest ofclarity, not all features of an actual implementation are described inthis specification. It will of course be appreciated that in thedevelopment of any such actual embodiment, numerousimplementation-specific decisions must be made to achieve thedevelopers' specific goals, such as compliance with system-related andbusiness-related constraints, which will vary from one implementation toanother. Moreover, it will be appreciated that such a development effortmight be complex and time-consuming, but would nevertheless be a routineundertaking for those of ordinary skill in the art having the benefit ofthis disclosure.

The present subject matter will now be described with reference to theattached figures. Various structures, systems and devices areschematically depicted in the drawings for purposes of explanation onlyand so as to not obscure the present disclosure with details that arewell known to those skilled in the art. Nevertheless, the attacheddrawings are included to describe and explain illustrative examples ofthe present disclosure. The words and phrases used herein should beunderstood and interpreted to have a meaning consistent with theunderstanding of those words and phrases by those skilled in therelevant art. No special definition of a term or phrase, i.e., adefinition that is different from the ordinary and customary meaning asunderstood by those skilled in the art, is intended to be implied byconsistent usage of the term or phrase herein. To the extent that a termor phrase is intended to have a special meaning, i.e., a meaning otherthan that understood by skilled artisans, such a special definition willbe expressly set forth in the specification in a definitional mannerthat directly and unequivocally provides the special definition for theterm or phrase.

According to some illustrative embodiments, various systems and methodsare disclosed for drilling a plurality of closely spaced wellbores foroil, gas, and water wells. In some embodiments, the various rigoperations, such as drilling, tripping, casing, cementing, and the likemay be performed simultaneously, thereby effectively increasing theefficiency of the rig operations while saving valuable rig time.

In some embodiments, the systems and methods for drilling a plurality ofclosely spaced wellbores include multiple machines on a singlemulti-function rig for performing the various rig operations. Not by wayof limitation, the multiple machines may include, for example, machinesadapted for: drilling a wellbore; tripping drill pipe/tubulars and adrill bit in or out of a wellbore; casing a wellbore; installing heatermachines in a wellbore; cementing a cased wellbore; producing an upperportion (sometimes called a “conductor hole”) of a wellbore; and/orperforming workover operations on existing wellbores.

In further embodiments disclosed herein, the systems and methods inwhich a multi-function multi-hole rig used for drilling, completing,and/or performing workover operations on multiple oil, gas or waterwellbores comprises multiple machines adapted to be movable on the rigitself to each of several hole locations without moving the entire rig.This may be accomplished by moving the machines around or on theperiphery of the rig. In one illustrative embodiment, such a rig mayhave a rig periphery, as viewed from above, which may be rectangular inshape. In other embodiments, such a rig may have a rig periphery, asviewed from above, which may be non-rectangular in shape. For example,the rig periphery may comprise a generally curved configuration, such asa circular shape, elliptical shape, oval shape and the like. In otherembodiments, the rig periphery may comprise a general polygonal shapeother than rectangular, such as octagonal, hexagonal, pentagonal,triangular and the like. Machines may be movable on a track or patharound such a periphery, or a separate movable support supporting themachines may be adapted to move the machines around the periphery fromone hole location to another.

Other embodiments disclosed herein may comprise movement apparatuslocated on or adjacent to the multi-function rig structure and adaptedfor moving each of the individual multiple machines relative to the rigstructure to positions proximate the multiple wellbore locations withoutmoving the entire rig. In one embodiment, the movement apparatus may beadapted to pick up a machine move it, and may comprise a crane, multiplecranes or a hoisting device. It should be noted that the term proximateas it is used herein and throughout the present disclosure is defined tocomprise adjacent, adjoining, on, contiguous, immediate, nearby, close,neighboring, near, coupled to, and coupled with.

In another embodiment of the present disclosure, coil tubing units maybe provided to aid in completion and drilling operations. In otherembodiments, workover machines may also be provided to perform workoveroperations of existing wellbores, such as the repair and/or stimulationof existing production wells and the like.

In yet another illustrative embodiment, the multi-function rig maycomprise a heater installation machine adapted for installing heatingdevices, apparatuses, tubulars and/or structure for a wellbore. A mudsystem may also be provided as part of the multi-function rig, which mudsystem may further include, for example, a mud pit, shakers, augers, mudpumps, de-gassers, de-sanders, de-silters, centrifuges, and the like.

Certain embodiments disclosed herein may also include pressure controlequipment disposed proximate the rig structure on the wellbore locationside. In some embodiments, the pressure control equipment may be adaptedto support drilling loads during rig operations. In other embodiments, aframe may be disposed proximate the pressure control equipment, which inturn may be adapted to support drilling loads. It should be noted that,within the scope of the present disclosure, pressure control equipmentmay include, for example, wellheads, blowout preventers, flowlineapparatus, diverter apparatus, and the like, as may generally be knownin the art of drilling and production operations, or as may subsequentlybe developed.

FIG. 3 illustrates one embodiment disclosed herein that comprises acenter-support drilling machine in which a drilling machine may berotatably mounted on a center support, e.g., a central pillar, so thatthe drilling machine may be rotatable on the center support forpositioning over multiple wellbore locations. In other embodiments,additional machines, such as tripping, casing running, heaterinstalling, cementing and the like may also be rotatably mounted on thecenter support. Moreover, in some illustrative embodiments one machinemay be mounted above or below another machine and/or staggered atdifferent levels on a center support.

As shown in FIG. 3, a system 10 comprises a base or rig floor 12 thatmay be supported by a plurality of supports 14. An upright pillar 20 maybe fixedly secured to the rig floor 12. An optional shroud 16 (sidesshown in dotted lines) may be provided for use in harsh weatherenvironments. The optional shroud 16 may comprise a top 17, and may alsoencompass the majority of the rig floor 12. A crane 18 may be rotatablymounted on a top 21 of the pillar 20. A platform 13 projecting from therig floor 12 may also be provided.

In the illustrative embodiment depicted in FIG. 3, six holes 15penetrate and extend through rig floor 12, each hole corresponding toand above a location on the ground below the rig floor 12 where awellbore is intended to be drilled and completed. In other embodiments,any number of such holes, both fewer and greater, may be provided, asmay correspond to the number of wellbores required for the specificationapplication.

A drilling machine 30 may be movably mounted for up and down movement ona beam 31, which may be part of a support 32 rotatably mounted on thepillar 20. Crossbeams 33 may be connected to rings 34 which encompassand rotate on the pillar 20. As shown in FIG. 3, a drawworks 40 may bemounted on the lower crossbeam 33 and supported by a beam 35 connectedto the lower crossbeam 33 and extending down to the top of the rig floor12.

A cartridge 50 with tubulars 52 therein (e.g., drill pipe) may besupported on the rig floor 12. In some embodiments, the cartridge 50 maybe adapted to be movable around the rig floor 12 and adjacent a desiredmachine. As shown in FIG. 3, the cartridge 50 may be adjacent thedrilling machine 30. Any suitable and desirable rig equipment andapparatuses may be located on the rig floor 12, such as an ironroughneck 58 and the like. Optional air treatment equipment 56 disposedon the rig floor 12 provides heated or cooled air to the system 10. Inother embodiments, the equipment 56 may be located near the system 10,but not on the rig floor 12. A bucket B may be disposed below the rigfloor 12 for collecting mud that may be circulated from the wellbore.

FIG. 4 shows another illustrative embodiment comprising a system 10 athat is similar to the system 10 of FIG. 3 (note that like referencenumerals indicate like system components). As illustrated in FIG. 4, anadditional support 32 a supports an additional machine 30 a (shownschematically). The additional machine 30 a may comprise any one of adrilling machine, tripping machine, a cementing machine, a casingmachine, a heater installation machine, or any other machine used oruseful on a drilling rig. In one embodiment, the additional machine 30 amay be connected to and supported by the same ring 34 as machine 30. Inother embodiments, there may be separate rings adapted for supportingthe additional support 32 a for the additional machine 30 a and itsrespective drawworks. Optionally, an additional machine (not shown)supported by an additional support (not shown) may also be rotatablymounted on the pillar 20.

According to some embodiments, the drilling machines, tripping machinesand casing running machines may comprise a tubular racking system thatmay be, in the traditional manner, disposed in front of the machine(s).As is known in many cases, a tubular racking system disposed in front ofthe machine(s) is a configuration in which the hole to be drilled isbetween the drilling machine and the tubular racking system and setbackarea. However, in other illustrative embodiments, a tubular rackingsystem may be located behind the machine(s) rather then in front of themachine(s). As used herein and throughout the present disclosure,tubulars are defined to comprise drill pipes, square pipes, wired pipes,collars, heavy weights, bottom hole assembly components, downhole tools,bottom hole assembly with bit, casing, and any other apparatus, tools,etc., as is known in the art of drilling, completions and/or workoverapplications, or subsequently developed.

FIGS. 5A-5D show further illustrative embodiments of the presentdisclosure. A system 100 comprises a rig floor 102 on four supports 104(three shown). Optionally, the system 100 may be mobile, and in somesuch embodiments may be mounted on wheels 106 (shown schematically). Inother embodiments, tracks may be used instead of wheels. As shown inFIG. 5D, the rig floor 102 has six holes 108 penetrating therethrough.Each of the six holes 108 is located above a location on the ground G atwhich it is intended to drill and complete a wellbore. As further shownin FIGS. 5A-5C, a drilling machine 120 is located adjacent one of theholes 108 and is drilling a wellbore 110 with a bit 114 on a drillstring 112.

In some illustrative embodiments of the present disclosure, the drillingmachine 120 is movable up and down on a track 122. As shown in FIG. 5A,a tubular rack 130 behind of the drilling machine 120 holdstubulars/drill pipe 132 (or, if desired, tubing or casing) for use inthe drill string 112. Optionally, as shown in dotted line in FIG. 5C,the system 100 has a harsh weather shroud 136 and an optional airtreatment system 138 (shown schematically) to heat or cool air. Thedrill machine 120 may be a pull-down drilling machine, a cylinder rig ora drawworks-driven machine.

FIG. 5B shows a tripping machine 140 on the rig floor 102 proximate ahole 108 through which a wellbore 109 has been drilled with the drillingmachine 120. In a typical rig operation, the tripping machine 140 isadapted to remove the drill pipe/tubulars 132 used by the drillingmachine 120 from the wellbore 109. In some embodiments disclosed herein,the tripping machine 140 may hang off the drill pipe on the tool jointupset at the rig floor 102 instead of using slips. In such embodiments,the hoisting mechanism may be positioned on either side of the hang offpoint (not shown).

In some illustrative embodiments, a separate cementing machine 150 mayalso be positioned for cementing casing in a wellbore. In the embodimentillustrated in FIG. 5A, the wellbore 111 to be cemented by the cementingmachine 150 (shown schematically in FIG. 5A) was previously drilled bythe drilling machine 120, and the drill pipe/tubulars were previouslyremoved from the wellbore 111 by the tripping machine 140. In thoseparticular embodiments when casing drilling is used, the casing may havebeen run by a tripping machine, or optionally by a casing runningmachine.

A driller's cabin 160 may also be located on the rig floor 102 so thatpersonnel in the driller's cabin can see each hole 108 and each machinelocated proximate a hole during rig operations.

Each of the machines 120, 140, 150 comprising the system 100 may beadapted to be movable across the rig floor 102. As shown in FIGS. 5A and5D, pathway 128 indicates movement options for each of the machines 120,140, 150. Any suitable movement paths may be used and any suitablemovement apparatus for moving the machines may also be used.

The tripping machine 140 may comprise a tubular rack system 142proximate thereto and the cementing machine 150 may comprise a tubularrack system 152 proximate thereto. For example, as shown in FIG. 5B, thetubular rack 130 may be positioned behind the drilling machine 120. Thisarrangement is the opposite of conventional tubular rack systems, whichare positioned in front of a drilling system and in which the holethrough which a well is drilled is positioned between a drilling systemand a tubular rack system. Locating the tubular rack system behind thedrilling machine (or behind another machine) has several advantages,such as saving space and allowing an unobstructed view of multipleoperations and/or multiple wells. Placing the tubular rack systemsbehind the drilling machine also enables auxiliary equipment to bebrought up close to the multi-function rig, and further allows otheroperations to take place in conjunction with the drilling, completionsand workover operations. Moreover, in other illustrative embodimentsdisclosed herein, a hoisting system may be part of a tubular racksystem. In still other embodiments, the tubulars/drill pipe may besupported, not by slips, but by two sides of the tool joint. In suchembodiments the hoisting mechanism picks up on the other two sides ofthe tool joint in order to eliminate the need for slips.

In some illustrative embodiments, the systems and methods disclosedherein may employ drilling machines in which a drilling device is moved,forced, or pulled down to facilitate wellbore drilling. In oneembodiment, a cylinder-powered drilling apparatus 120 a, as shown inFIG. 5B, includes one, two or more powered cylinder apparatuses thatpull a drilling device down to force it into the earth. Power cylinders127 have rods 129 connected to a plate 133 that moves on tracks 137. Thepower cylinders 127 are connected to the drilling apparatus 120 a.Extension of the rods 129 upwardly results in pushing up of the sheavesthat then pull up a top drive or tripping machine. Retracting of therods 129 results in pulling down on other sheaves that then pull down onthe top drive or on the tripping machine. Power cylinders can beadvantageous as compared to, for example, a typical top drive rig, insaving space, in ease of control, and in the ability to keep a top drivefrom colliding with the rig floor or into the crown. In one particularembodiment, the drilling machine 120 may have a 50-to-75 ton top driveor power swivel. In other embodiments, for any system disclosed herein,the drilling machine may be a 50-to-1250 ton top drive system.

In other illustrative embodiments, a road module may be providedadjacent one multi-hole location or extending by a plurality ofmulti-hole locations. In some embodiments, a crane and/or driller'scabin may be movably positioned on the road module and one or moremulti-function multi-hole rigs may be located adjacent the road moduleand movable with respect to the road module from one multi-hole locationto another.

FIGS. 6A and 6B yet another illustrative embodiment, comprising a system200 which includes multiple systems (generally designated as system 100in FIG. 6A) proximate a road module 300. Multiple wellbores 210 may bedrilled, completed, or worked over by the multiple systems 100. In theembodiment illustrated in FIG. 6A, two systems 100 a and 100 b are showndisposed at system location 201, although three or even more systems 100may be provided as part of system 200.

The road module 300 includes connected road sections 302 supported by aplurality of supports 304. In one embodiment, the supports 304 extenddown to bedrock at the system location 201. For example, the supports304 may extend through any one of a variety of surface materialsoverlying the bedrock as may typically be found at drilling sitelocations, such as top soil, tundra, muskeg, peat, sand, unstable soilor other material, ice and the like. Optionally, a crane 310 may besemi-permanently or movably mounted on the road sections 302 for use inoperations of any one of the systems 100.

In one embodiment disclosed herein, each system 100 may comprise all ofthe machines needed to drill, complete, and/or work over multiplewellbores. Moreover, in some embodiments, each system 100 may be adaptedto move from one wellbore to another within the system location 201,thereby being able to perform rig operations on multiple wellbores 210.For example, one system 100 may be disposed above a first location of anintended wellbore 210 and thereafter perform typical rig operations,such as drilling the wellbore, tripping out the drill pipe/tubulars,casing the wellbore, cementing the casing in place, and the like. Inthis embodiment, the wellbore is cased and cemented immediately uponcompletion of the drilling and tripping operations. After completing allrig operations at the first location, the system 100 may then be movedand disposed above a second location of an intended wellbore 210 andthereafter perform all rig operations as previously performed at thefirst location. Again, upon completion of rig operations at the secondlocation, the system 100 may again be moved and disposed above multipleadditional intended wellbores 210, and thereafter performing andcompleting the same rig operations at each. Moreover, in someembodiments, multiple systems 100 may be disposed within the systemlocation 201 to simultaneously perform and complete rig operations onmultiple wellbores 210.

In other embodiments, each system 100 may only comprise certain specificmachines that perform certain specific drilling, completions, and/orworkover functions. For example, and not by way of limitation, thesystem 100 a depicted in FIG. 6A may be a drilling/tripping systemcomprising a drilling machine 120 b with its associated tubular rackingsystem 120 c and a tripping machine 140 b with its associated tubularracking system 140 c. System 100 b, on the other hand, may be acasing/cementing system comprising a casing machine 150 c with its racksystem 150 e and a cementing machine 150 d with its rack system 150 f.In some particular embodiments of the present disclosure, each of thesystems 100 a and 100 b may be further adapted to be movable from onewellbore to another wellbore within the system location 201. Forexample, the drilling/tripping system 100 a may be disposed above afirst location of an intended wellbore 210, at which location the system100 a may then drill the wellbore and trip out the drill pipe/tubulars.After completion of the drilling and tripping operations, thedrilling/tripping system 100 a may then be moved and disposed above asecond location of an intended wellbore 210 while the casing/cementingsystem 100 b may be moved and disposed above the first locationpreviously drilled by system 100 a. The casing/cementing system 100 bmay then case the wellbore at the first location and cement the casingin place, and the drilling/tripping system 100 a may perform rigoperations at the second location. It should be noted that, while notessential to the overall operation of system 200, the operations bysystem 100 b at the first location and system 100 a at the secondlocation may be performed simultaneously. Moreover, as rig operationsare completed by drilling/tripping system 100 a at the second location,system 100 a may be moved to third and fourth intended wellborelocations, and so on, and as rig operations are completed bycasing/cementing system 100 b, system 100 b may be moved to the secondand third locations previously drilled by system 100 a, and so on.

In yet another illustrative embodiment, each of the systems 100 may beadapted to perform all of the operations necessary to complete only asingle specific section of the wellbore. For example, system 100 a maycomprise all machines and systems required to drill trip, case, andcement the first section of the wellbore. System 100 b, on the otherhand, may comprise all machines and systems required to drill, trip,case, and cement the second section of the wellbore. Additional systems100 may also be provided for performing similar rig operations on othersections of the wellbore, as might be necessary for the specificapplication. As with the previously described embodiment, each of thesystems 100 may be adapted to be movable from one wellbore to anotherwellbore within the system location 201, where the operations necessaryto complete the wellbore section for which each system 100 may bespecifically adapted might be sequentially performed.

Finally, it should be noted that for each of the various embodiments ofsystem 200 as illustrated by FIGS. 6A and 6B and described above, any orall of the systems 100 may also comprise a heater installation machineadapted to install heaters in a wellbore.

FIGS. 7A and 7B illustrate an embodiment of a drilling system forperforming progressive work on multiple wells. As shown in FIG. 7A,there are sixteen wells to be drilled (1-8 in line A and 1-8 in line B).As illustrated in FIG. 7A, a system 100 drills all the wells below holes1-4, line A and 1-4, line B, and completes (or trips pipe/tubulars outof) hole 1A and 1B (or only some of them). In one embodiment, the system100 completes wells on lines 1-3 and partially completes wells on line4. Then, the system 100 is moved so that it is above wellbore locations4-7, line A and 4-7, line B. Thus, while various machines may be workingon the already-drilled holes, the drilling machine can drill thewellbores at locations 5 of lines A and B, and so on for all sixteenwellbores.

FIG. 8 shows yet another illustrative embodiment, comprising a system260 with systems 10 a and a road module system 300. The systems 10 amove down a system location 301 (left-to-right in FIG. 8) drilling andcompleting multiple wellbores corresponding to a plurality of sets ofmultiple holes at hole locations 261, 262, 263, etc. As with theembodiments illustrated in FIGS. 3 and 4, each set of multiple holesillustrated in FIG. 8 comprises six holes at each hole location 261,262, 263, etc. However, particular embodiments may include as many holesas might be appropriate for the specific application, including, but notlimited to, two holes, three holes, four holes, five holes, seven holes,eight holes or even more. As FIG. 8 shows, a system 10 a can be of anyheight necessary to achieve wellbores of the required depth.

FIG. 8A shows a further embodiment wherein a road module is supported bypillars P. The cross-section view shown in FIG. 8A illustrates a liteduty road top LD supported directly by the pillars P. The lite duty roadtop LD may, in some embodiments, support an optional heavy duty road topHD, which may comprise selectively removable sections. In still otherembodiments, the lite duty road top LD may comprise selectivelyremovable sections, or, in cases when the heavy duty road top HD ispresent, may be eliminated entirely.

In certain embodiments as disclosed herein, a rig is provided on whichone or more certain machines may be movable around the periphery of therig, and one which one or more other machines may be movable across aportion of a rig. For example, in a rig according to one illustrativeembodiment, a drilling machine and a cementing machine may be movablearound the periphery of a rig, whereas a tripping machine may be movableacross the rig from one hole location to another hole location. In yetanother embodiment, machines other than a drilling machine may bemovable around the periphery of a rig, and a drilling machine may bemovable across the rig from one hole location to another hole location.

In other embodiments of the present disclosure, multiple machines andmultiple wellbore locations may be located so that, from a singledriller's cabin on the rig, all machines and all wellbore locations canbe viewed and monitored during the various stages of drilling, tripping,cementing, completions, and/or workover operations performed on multipleholes. In one particular embodiment, a cabin system may be provided inwhich the driller's cabin is movable to multiple positions on the rigeither across the rig or on its periphery. In another embodiment, one ormore of the multiple machines may be movable on the rig, either acrossthe rig or on its periphery. In any of the various embodiments of thesystems disclosed herein, the driller may also move or be moved in achair around a driller's cabin, and, in one aspect, he may be located inthe center of the floor and the chair rotates to view each wellbore.

FIG. 9A shows a particular embodiment comprising a site location 401with multiple wellbore sites W1, W2, W3, and W4. In other embodiments,the number of wellbore sites at a given site location may be varied asnecessary to meet the specific requirements of a particular application,for example, two, fifty, two hundred, etc. In many embodiments thespacing between wellbore sites W1, W2, W3, etc., will be approximately10 feet, however both smaller and larger wellbore site spacings arewithin the scope of the present disclosure.

FIG. 9B shows a system 400 according to yet another embodiment thatcomprises a driller's cabin 402 on a base 404 from which operationspersonnel may at all times be able to view multiple machines comprisingthe system 400 and located at the system's periphery. The multiplemachines illustrated in FIG. 9B may include, but would not be limitedto, a drilling machine 410, a tripping machine 420 and a cementingmachine 430. In some illustrative embodiments, the cementing machine 430may also perform casing functions, and in other embodiments, a separatecasing machine (not shown) may be provided. Each machine may be mountedfor movement along a pathway 406, such as a track, groove, rail system,and the like. In some embodiments, the base 404 may have the pathway 406rotatably mounted therearound, and the entire pathway 406 may rotatewith respect to the base 404. Optionally, the multiple machines may bemounted on and supported by the rotatably mounted pathway 406. In otherembodiments, the pathway 406 may be fixedly mounted on the base 404, andthe base 404 may rotate. In yet another embodiment as disclosed herein,a driller chair may be adapted rotate, such that operations performed byany one of the multiple machines 410, 420, 430, etc., at any one of themultiple wellbore locations W1, W2, W3, etc., can be directly viewed bythe driller.

In another embodiment of the present disclosure, the multiple machinescomprising the system 400 may include a heater running machine 440adapted for installing a heater function in or near any wellbore drilledwith the system 400.

FIG. 9C illustrates one embodiment of the system 400 during a typicalrig operation. In this illustrative embodiment, the drilling machine 410may be positioned proximate to and above wellbore W1, the trippingmachine 420 may be positioned proximate to and above wellbore W4, andthe cementing machine 430 may be positioned proximate to and abovewellbore W3. During operation shown, the drilling machine 410 may bedrilling wellbore W1 and the tripping machine 420 may be trippingtubulars from wellbore W4, which had previously been drilled by drillingmachine 410. Furthermore, the cementing machine 430 may be cementing thecasing in place in wellbore W3, which was previously drilled by drillingmachine 410, and from which the tubulars were previously tripped bytripping machine 420. In some embodiments, the casing that is beingcemented in wellbore W3 by the cementing machine 430 was previouslyinstalled in wellbore W3 by the cementing machine 430, which in thisembodiment may comprise a casing installation apparatus adapted toinstall casing in a drilled wellbore. In other embodiments, the casingthat is being cemented in wellbore W3 was previously installed inwellbore W3 by an optional separate casing apparatus 450. As the rigoperations illustrated in FIG. 9C continue, the next wellbore to bedrilled by drilling machine 410 will be wellbore W2, which may occurafter each of the machines comprising system 400 are rotatably movedalong pathway 460 in a clockwise direction.

In another embodiment illustrated in FIG. 10, a system 500 may comprisea drilling machine 510 disposed on a pathway 506, similar to the pathway406 of system 400. A tripping machine 520 and a cementing machine 530are disposed on and adapted to move across a base 504, similar to thebase 404 of system 400. In some embodiments, a heater installer may alsobe disposed on and adapted to move across the base 504. Optionally, theheater installer may be disposed on the pathway 506. A tubular rackingsystem 508 may be provided behind of the drilling machine 510, and mayeither be disposed on the pathway 506 or mounted to another adjacentstructure. In other embodiments, the system 500 may also comprise acrane or hoist (not shown) adapted for lifting and moving systems,machines and equipment during rig operations.

FIG. 11 illustrates a system 560, which is an optional embodiment ofsystem 500 according to the present disclosure. System 560 may comprisea drilling machine 562 that is disposed on and movable across a base564, similar to the base 504 of system 500. System 560 further comprisesa tripping machine 566 and a cementing machine 568 disposed on a pathway569, similar to the pathway 506 of system 500. In some embodiments,system 560 may also comprise a casing machine (not shown), which may bedisposed on the pathway 569, or optionally disposed on and adapted tomove across the base 564.

According to the embodiment shown in FIG. 12, a driller's cabin may bein a fixed position connected to a base of a system, or alternatively tosome other structure proximate thereto. In some embodiments, thedriller's cabin may be located so personnel therein can view alloperating machines and/or all well locations simultaneously. In otherembodiments, viewing may be possible via direct line of sight, camera(s)and/or rotating a drill chair to a desired position for viewing.

FIG. 13 shows an optional disposition of a driller's cabin 403. Thedriller's cabin 403 is disposed on the pathway 406 and, as with any orall the machines 410, 420, 430, may be adapted to be movable withrespect to the base 404. As illustrated in FIG. 13, the driller's cabin403 is located on the pathway 406 between machines 410 and 420, howevera crane or other movement apparatus may move the driller's cabin 403 toany desired location on the pathway 406. For example, the driller'scabin 403 may be located between machines 420 and 430, or optionallybetween machines 430 and 410. In the illustrative embodiment shown inFIG. 14, a driller's cabin 403 a may have its own dedicated pathway 406a which, in one embodiment may be adapted to move around both a pathway406 and a base 404.

In some embodiments disclosed herein, multiple rig operations, such as,for example, drilling, tripping, casing, cementing and the like, maysimultaneously (or at least near-simultaneously) performed by amulti-function rig on multiple wellbores without moving the rig. Inoperation, a drilling machine disposed on the multi-function rig may bemoved to a new position on the rig to commence drilling a new wellbore.In the interim, a tripping machine also disposed on the rig may be movedinto place over a drilled wellbore to commence tripping out drillpipe/tubulars and the drill bit that were previously used by thedrilling machine to drill the wellbore. In another embodiment of thepresent disclosure, one in which two wellbores have been thus drilled bythe drilling machine, a cementing machine also disposed on the rig maybe moved over the first drilled wellbore to commence a cementingoperation to cement in place casing that was previously installed by thetripping machine. Alternatively, the casing at the first drilledwellbore may have been installed by a separate casing running machinemoved to that wellbore after completion of the tripping operation by thetripping machine. In the interim, the tripping machine may be moved overa second-drilled wellbore to trip out drilling pipe/tubulars and drillbit from the second wellbore as the drilling machine is moved to a thirdwellbore and commences drilling operations there. Disposable and/orabandonable bits may be used in systems and methods according to someillustrative embodiments, and in particular embodiments part of awellbore may be drilled using a drill bit on drill pipe/tubulars, andpart may be drilled using a casing drilling method.

In one particular embodiment disclosed herein, the drilling machine maycomprise a casing drilling machine, wherein a tripping machine may notbe required. In certain other embodiments disclosed herein, multiplecasing drilling machines may be disposed on one rig for simultaneouslyperforming rig operations on multiple wellbores.

FIG. 15 shows one illustrative embodiment of the present disclosurecomprising a system 600 which includes an erectable rig structure 602with a floor 604. In some embodiments, as shown in FIG. 15A, an activerig mud system 620, comprising a plurality of shale shakers 606(supported by the rig structure 602) and a mud pit 606 p may be disposedunder the floor 604. In one particular embodiment, the active rig mudsystem 620 may also comprise an auger apparatus 606 a for movingmaterial in and from the mud pit 606 p. The shakers 606 and the mud pit606 p may be located between the wellbore locations 611-614, and mayalso be adapted to be movable thereinto and therefrom as may be dictatedby the specific application. FIG. 15D illustrates one embodiment of theactive rig mud system 620 and its relationship to the rig structure 602with the rig structure 602 in the fully erected position.

In some embodiments, pressure control equipment (generally indicated as608) may be disposed proximate one or more of the wellbore locations611-614, and may include such equipment as a flowline; a blowoutpreventer apparatus, a diverter apparatus, wellhead 608 w and the like.As shown in FIG. 15, multiple blowout preventer stacks 608 may belocated over each of the wellbore locations 611-614. In otherembodiments disclosed herein, wells to be drilled at wellbore locations611-614 may be spaced as close as eight feet or a far as twenty fivefeet from wellbore to wellbore, but it should be noted that any wellborespacing may be used depending on the specific application. In oneparticular embodiment, the wellbores are spaced approximately fifteenfeet apart.

A variety of machines may be used with the system 600 including, but notlimited to, any machine used in any embodiment of any system disclosedherein. In one particular embodiment, two drilling machines DM1, DM2 anda tripping machine TM1 may each be connected to or disposed proximate tothe rig structure 602. Any of the machines DM1, DM2, TM1 may be adaptedto be movable to a position proximate any of the wellbore locations611-614.

In some embodiments, one or more of the machines DM1, DM2, TM1 may besupported by the pressure control equipment 608. In such cases, thepressure control equipment 608 may be adapted to directly supportdrilling loads generated during drilling operations, such as the loadsof the drilling machine DM1, DM2, a tubular string connected to thedrilling machine, equipment connected to the tubular string, and thelike. In yet other embodiments of the present disclosure, any one or allof the machines DM1, DM2, TM1 may be supported by a structural support,such as a separate frame 608 f, which may be a blowout preventer frameand the like, and which may be disposed adjacent to or around thepressure control equipment 608, in which case the drilling loadsgenerated during drilling operations as noted previously would besupported directly by the frame 608 f. Furthermore, as shown in FIG. 15and described above, in certain illustrative embodiments disclosedherein, the frame 608 f, such as a blowout preventer frame, may be atleast partially supported off of one or more components of the pressurecontrol equipment 608, such as, for example, the blowout preventerapparatus, the wellhead 608 w, and the like.

As shown in FIG. 15, a driller's cabin 616 may also be disposed on therig structure 602 and another cabin 618 (or an extension of thedriller's cabin 616) may be disposed on an erection structure 622 abovethe active rig mud system 620. The erection structure 622 may compriseposition locking apparatuses 621, and may further comprise powerederection apparatuses 623, 624 such as, for example, power cylinderapparatuses, lead screw apparatuses, motorized apparatuses and the like.In some embodiments, the driller's cabin 616 and/or cabin 618 may beadapted to be movable from one end of the rig structure 602 to theother. In those embodiments of the present disclosure wherein themachines DM1, DM2, TM1 are directly supported by the pressure controlequipment 608, or alternatively by the frame 608 f, the machines DM1,DM2, TM1 may advantageously be out of the way of a driller's cabin 616as it moves on the rig structure 602. See, for example, FIG. 17N,described below.

As illustrated in FIG. 15B, the driller's cabin 616 may be disposed onthe floor 604 of the rig structure 602. Additionally, in particularembodiments as shown in FIG. 15A, the rig floor 604 may comprise rails604 r adapted to facilitate the movement of equipment and otherapparatus along the length of the rig structure 602. FIG. 15Cillustrates one embodiment wherein a crane 630 may be disposed on therails 604 r of the floor 604, and in specific embodiments, the crane 630may comprise a base 630 b and roller apparatuses 632 adapted to engagewith and move on the rails 604 r.

FIGS. 16A-16C illustrate various steps in the erection of the rigstructure 602. Powered cylinder apparatuses 624 adapted to erect the rigstructure 602 are connected between a top 602 a and a bottom 602 b ofthe rig structure 602. In operation, the powered cylinder apparatuses624 are energized and the rig structure 602 begins to rise. FIGS. 16A16B shows two illustrative positions of the rig structure 602 as itcontinues to rise. FIG. 16C further shows the rig structure 602 after ithas reached its full height and is locked in place with lockingapparatuses 625. As shown in FIGS. 16A and 16B, the rig structure 602comprises four multi-part legs (generally indicated as 605), eachmulti-part leg comprising a base 605 a, a pivotably connectedmid-section 605 b and an upper part 605 c.

FIGS. 17A-17S show various steps that may be employed in one method ofoperating a multi-function rig using the system 600 according to oneillustrative embodiment of the present disclosure. The followingdescription of the various embodiments illustrated in FIGS. 17A-17Sshould only be considered as representative of the method or methodsdescribed herein, as many of the steps may be performed in a differentsequence, may include additional steps not described, or may beeliminated altogether without materially affecting the subject matterdisclosed herein.

As shown in FIG. 17A, a blowout preventer stack 608 may be lifted bylifting apparatus, such as, for example, a crane 630 and the like, andplaced in position over wellbore location 613. Thereafter, asillustrated in FIG. 17B, a drilling machine DM1 may be moved proximateone end of the rig structure 602 opposite the end with the driller'scabin 616. The crane 630 may then proceed to begin lifting the drillingmachine DM1. FIG. 17C shows one illustrative position of the drillingmachine DM1 as it is being lifted by the crane 630, and FIG. 17Dillustrates the crane 630 holding the drilling machine DM1 upright atthe end of the rig structure 602. FIG. 17E further shows the drillingmachine DM1 after it has been rotated by the crane 630 to the back sideof the rig structure 602 in advance of moving the crane 630 along therails 604 r of the floor 604 into position above wellbore 613 whilesupporting the drilling machine DM1. FIG. 17F shows the drilling machineDM1 in position above the stack 608 while the drilling machine DM1 isstill supported by the crane 630. As shown in FIG. 17G, a tubularerector apparatus 640 with tubulars for performing tripping operationshas been moved proximate the well location 613. Tubular erectorapparatus 640 may be adapted to supply, for example, tubulars fordrilling operations performed by the drilling machine DM1, casing fortripping operations performed by a tripping machine or casing machine,and the like.

FIG. 17H illustrates a further step in a method of operating themulti-function rig, after the crane 630 has placed another blowoutpreventer stack 608 in position over wellbore location 614. As furthershown in FIG. 17I, the crane 630 may connect to and raise a seconddrilling machine DM2 at the end of the rig structure 602 opposite thedriller's cabin 616. Thereafter, the second drilling machine DM2 may bemoved into place above wellbore location 614, as illustrated in FIG.17J, using steps similar to those previously outlined for movingdrilling machine DM1. In the interim, the drilling machine DM1 maycommence drilling operations at wellbore location 613. As previouslydescribed with respect to FIG. 15 above, in certain illustrativeembodiments, the blowout preventer stacks 608 positioned over wellborelocations 613 and 614, as well as any blowout preventer stack 608positioned over any wellbore location described herein, may be adaptedto directly support any drilling loads that may be generated duringdrilling operations. Accordingly, in at least some embodiments, thedrilling machines DM1 and/or DM2 may be supported by one or morestructural supports attached to each respective blowout preventer stack608, as illustrated in FIG. 17J. In such embodiments, the drilling loadsgenerated the drilling machines DM1 and/or DM2 during drillingoperations may thus be imposed on a respective pressure controlequipment device, e.g., a blowout preventer stack 608.

As shown in FIG. 17K, a second tubular erector apparatus 640 has beendisposed proximate wellbore location 614 to supply tubulars for drillingoperations to be performed by the second drilling machine DM2. Alsoshown in FIG. 17K, the crane 630 has moved back to the end of the rigfloor 604 opposite the end with the driller's cabin 616.

In one embodiment of operating the multi-function rig, FIG. 17Lillustrates a next step wherein the crane 630 has positioned anotherblowout preventer stack 608 above wellbore location 611, and anothertubular erector apparatus 640 has been positioned proximate the welllocation 611. Meanwhile, in some embodiments drilling may commence withthe second drilling machine DM2 at wellbore location 614, and drillingmay continue with drilling machine DM1 at wellbore location 613.

After the wellbore has been drilled at wellbore location 613, thedrilling machine DM1 may be moved by the crane 630 from the stack 608 atwellbore location 613 and positioned above the stack 608 located atwellbore location 611 for drilling operations thereat. FIG. 17Millustrates one embodiment wherein drilling machine DM1 is positionedabove wellbore 611 while drilling operations continue with the seconddrilling machine DM2 at wellbore location 614.

In a further illustrative embodiment disclosed herein, FIG. 17N shows atripping machine TM1 that has been moved by the crane 630 into place atwellbore location 613. In some embodiments, the tripping machinecommences a tripping operation at wellbore location 613, such as, forexample, tripping out tubulars/drill pipe and bit, tripping in casing,and the like, while drilling may commence with the drilling machine DM1at wellbore location 611 and drilling may continue with the seconddrilling machine DM2 at wellbore location 614.

As shown in FIG. 17O, the crane 630 has moved another blowout preventerstack 608 (or other such pressure control equipment, if it is used) intoposition at wellbore location 612. FIG. 16O further shows that anothertubular erector apparatus 640 has also been positioned proximatewellbore location 612. In some illustrative embodiments, the machinesDM1, DM2 and TM1 may continue their operations in the interim atwellbore locations 611, 614 and 613, respectively.

In yet another embodiment of the present disclosure, FIG. 17Pillustrates the tripping machine TM1 positioned above wellbore location614, to which it has been moved by the crane 630 after completion oftripping operations at wellbore location 613. Thereafter, a cementingmachine adapted to perform casing cementing operations may be positionedby the crane 630 above the cased wellbore location 613. In someillustrative embodiments, the drilling machine DM1 may continue drillingoperations at wellbore location 611, the tripping machine TM1 maycommence tripping operations at wellbore location 614, and the cementingmachine CM1 may commence cementing the casing in place in wellbore 613.FIG. 17P also shows the crane 630 supporting the second drilling machineDM2, which was removed from above wellbore location 614 after completionof drilling operations thereat, and in advance of positioning it abovewellbore location 612. FIG. 17Q further illustrates the drilling machineDM2 positioned above wellbore location 612. In certain embodimentsdisclosed herein, drilling at wellbore location 612 may commence withdrilling machine DM2, while the machines DM1, CM1 and TM1 continueoperations.

In yet another embodiment, FIG. 17R shows the tripping machine TM1positioned above wellbore location 611, to which it has been moved bythe crane 630 after completion of tripping operations at wellborelocation 614. The cementing machine CM1 is now positioned above wellborelocation 614, to which it was moved by the crane 630 after completingcementing operations at wellbore location 611. In some embodiments ofthe present disclosure, the tripping machine TM1 commences with atripping operation at wellbore location 611, while the drilling machineDM2 continues drilling operations at wellbore location 612 and thecementing machine CM1 commences cementing casing in the wellbore 614.FIG. 17R also shows an additional embodiment wherein the crane 630 issupporting the drilling machine DM1, which was removed from abovewellbore location 611 after completion of drilling operations thereat,and in advance of positioning it above a new wellbore location 615. Asseen in FIG. 17R, another stack 608 has been positioned above wellborelocation 615, and an additional tubular erector apparatus 640 has beenpositioned proximate thereto.

According the embodiment illustrated in FIG. 17S, the drilling machineDM1 may commence drilling operations at wellbore location 615, while inthe interim the second drilling machine DM2 completes a drillingoperation at wellbore location 612 and the cementing machine CM1completes the cementing operations at wellbore 614.

As would readily be appreciated from the forgoing description of thevarious methods, machines, and embodiments illustrated in FIGS. 17A-17S,similar operations involving machines DM1, DM2, TM1 and CM1 may continueuntil all such operations have been performed at each and every wellborelocation proximate both sides of rig structure 602. It should be notedthat the order of operations as shown in FIGS. 17A-17S may be changed,reduced, added to, modified and the like, so as to best suit specificrig operations and plans. The number of wellbores drilled, cased,completed and worked on, and the order in which the operations areperformed may also be changed as required for the specific application.

FIG. 18 shows a system 700 according to one illustrative embodimentdisclosed herein, comprising a rig structure 702 (like the rig structure602) wherein a driller's cabin 716 (like the driller's cabin 616) hasbeen adapted to move along the length of the rig structure 702. In oneparticular embodiment, the floor 704 comprises rails 704 r (like therails 604 r), and the driller's cabin 716 may be mounted on a base 720comprising a plurality of roller apparatuses 722. Each of the rollerapparatuses 722 may be adapted to engage with the rails 704 r andfacilitate movement of the base 720 on the floor 704. It should beappreciated that any of the systems disclosed herein may comprise amovable driller's cabin so configured as that of the system 700 asherein described and illustrated in FIG. 18.

FIG. 19 illustrates yet another embodiment of the present disclosure,wherein a system 730 comprises a rig structure 732 (like the rigstructures 602 or 702) and a floor 734. In some embodiments, an activerig mud system comprising a series of shale shakers 736 may be disposedunder the floor 734. Particular embodiments may comprise two cranes 731,733, each of which may be movably mounted on the floor 734. Each crane731, 733 may comprises a base 735 and a plurality of roller apparatuses738 adapted to engage a rail 734 r comprising the floor 734, therebyfacilitating movement of the cranes 731, 733 along the length of the rigstructure 732.

The system 730 may further comprise a driller's cabin as in any systemdisclosed herein. By way of example but not limitation, in someembodiments the system 730 may comprise the driller's cabin 616 ofsystem 600 as illustrated in FIG. 15A, or alternatively the system 730may comprise the driller's cabin 716 of system 700 as illustrated inFIG. 18. In other illustrative embodiments, the system 730 may comprisea driller's cabin 739 as shown in FIG. 19. The driller's cabin 739 maybe spaced apart from the rig structure 732, but positioned for viewingof the entire rig structure 732 and operations conducted therewith. Itshould be appreciated that any of the systems according to the presentdisclosure may comprise embodiments wherein a driller's cabin 739 may bespaced apart from the rig structure. Moreover, it should also beappreciated that any of the systems disclosed herein may comprisemultiple movable cranes such as the cranes 731, 733 comprising thesystem 730.

FIGS. 20A-20C disclose yet another embodiment according to the presentdisclosure. FIG. 20A shows a system 750 comprising a rig structure 752,a floor 754, and an optional roof 756. In some embodiments, the system750 may be completely enclosed as described for the various systemsdisclosed herein. Multiple machines for performing rig operations may bemovably mounted on the structure 752, including any machine or machinesassociated with one or more of the systems and embodiments describedherein, including, for example, drilling machines, tripping machines,casing machines, cementing machines and the like. According to theembodiment shown in FIG. 20C, the system 750 may comprise a plurality ofdrilling machines 760, a tripping machine 762, and a plurality ofcementing machines 764. In some embodiments, a superstructure 758 maysupport a movable crane 770, which is adapted to move any of themachines 760, 762, 764 to any location within the system 750. The system750 may be located over multiple wellbore locations, one wellborelocation corresponding to each of the six machines as shown in FIG. 20C.The system 750 may also comprise a driller's cabin 772, wherein thedriller's cabin may be configured like any driller's cabin described forany of the systems and embodiments disclosed herein. In one particularembodiment, the driller's cabin 772 may be adapted to be movable downthe length of the floor 754 during phases of rig operations when themachines are moved out of the way.

Another embodiment disclosed herein comprises a multi-function rig witha rig structure, wherein the multiple machines that perform rigoperations, such as drilling, completion and/or workover applicationsand the like, may be located at the rig structure side that includes thewellbore locations. In some such embodiments, the tubular holders andtubular movement apparatus may be positioned at the side of the rigstructure opposite the wellbore locations. In other such embodiments, inwhich the rig structure as seen from above may be of a rectangularshape, the tubular holders and tubular movement apparatus may be locatedon either of the ends, or lateral sides, of the rig structure. In someembodiments, the tubular movement apparatus enable tubulars to be movedfrom one side of the rig structure to the side of the rig structure thatincludes the wellbore locations. According to some embodiments, thetubulars may be passed by the tubular movement apparatus from within therig structure, and in other embodiments the tubulars may be passed overthe rig structure. In yet other embodiments, the tubulars may be passedfrom the side or sides of the rig structure.

In some embodiments disclosed herein, the tubular holders may wing (thatis, be placed to the side of) the catwalk and trough of a tubularmovement apparatus. In other embodiments, a frame may be disposed aroundthe tubular holder, and the catwalk and trough of the tubular movementapparatus may be positioned on the frame and above the tubular holder.

FIG. 21 shows one illustrative embodiment of the present disclosurecomprising a multi-function rig system 1000 that is a variation of themulti-function rig system 600 illustrated in FIGS. 15-17S, and thefurther embodiments illustrated in FIGS. 18 and 19. In one embodiment,the system 1000 may be configured such that the wellbore locationsWB1-WB6 are located on one side, that is, the wellbore side 1100, of therig structure 1002, and tubular holders 1020 and tubular movementapparatus 1010 are located on the opposite side, that is the tubularholder side 1101, of the wellbore location side 1100. This configurationprovides ample space on the wellbore location side 1100 for theplacement of completion and production equipment, such as, for example,production tubing, heating pipes, and the like.

Similar to the system 600, the multi-function rig system 1000 consistsof an erectable rig structure 1002 comprising an elevated floor 1004. Insome embodiments, an active rig mud system comprising a plurality ofshale shakers 1006 with mud pit(s) may be disposed under the elevatedfloor 1004. As with the system shown in FIG. 15A, some embodiments ofthe system 1000 may further comprise an auger apparatus for movingmaterial in and from the mud pit. The shale shakers 1006 and the mud pitmay be located within the rig structure 1002 and behind the wellborelocations WB1-WB6. In particular embodiments, additional equipmentcomprising the active rig mud system may also be located within theerectable rig structure 1002, such as, for example, a de-sander, ade-silter, a de-gasser 1016, and the like. In certain embodiments, anoptional centrifuge 1015 may be used in lieu of the de-sander andde-silter. In some embodiments, the shale shakers 1006, the mud pit(s),the de-gasser 1016, the centrifuge 1015 and any other equipmentassociated with the active rig mud system may each be adapted to beselectively movable out from within the rig structure 1002 independentof the wellbore locations WB1-WB6. In a particular embodiment, mud pumps1029 may be located at one end—i.e., the lateral side 1102—of the rigstructure 1002 as illustrated in FIGS. 21 and 21A.

Also similar to the system 600, the multi-function rig system 1000 maycomprise an erection structure 1022. In one embodiment, the erectionstructure 1002 may comprise position locking apparatuses 1021, and mayfurther comprise powered erection apparatuses 1023, such as, forexample, power cylinder apparatuses, lead screw apparatuses, motorizedapparatuses, and the like.

The multi-function rig system 1000 may in some embodiments furthercomprise a hydraulic power unit 1018 and/or electric power unit 1019disposed on the rig structure 1002 and supported by the erectionstructure 1022. In one embodiment, a driller's cabin 1016 may bedisposed on the hydraulic power unit 1018 or the electric power unit1019. The driller's cabin 1016 may be approximately centrally located onthe rig structure 1002, whereas in other illustrative embodiments, itmay be adapted to be movable from side to side. In certain embodiments,the driller's cabin 1016 may be movable on the rig's periphery, ormovable across the rig floor, or movable across a module of the rig,such as along the length of the hydraulic power unit 1018 or theelectric power unit 1019.

In some embodiments of the system 1000, pressure control equipment(generally indicated as 1008) may be disposed proximate one or more ofthe wellbore location WB1-WB6, and may comprise such equipment as aflowline, a blowout preventer apparatus, diverter apparatus, wellhead1008 w and the like. As shown for the embodiment illustrated in FIG. 21,blowout preventer stacks 1008 may be located over each of the wellborelocations WB1-WB6.

As described with respect to system 600, a variety of machines commonlyused for performing rig operations may be used with the system 1000,including, but not limited to, any machine used in any embodiment of anysystem disclosed herein. In some embodiments, the multiple machinesassociated with the rig operations comprise, for example, a drillingmachine DM1, a tripping machine TM1, a workover machine, a coil tubingunit, a casing drilling machine, a casing machine, a workover machine, acementing machine, a heater installation apparatus, an auxiliarydrilling unit, and the like. In one embodiment disclosed herein, each ofthe multiple machines are preferably disposed on the side of thedrilling structure 1002 that includes each of the wellbore locationsWB1-WB6—i.e., the wellbore location side 1100. Moreover, the variousmachines associated with the drilling operations may be placed proximateat least one of the wellbore locations WB1-WB6, and further may beadapted to be movable relative to the rig structure 1002.

In some embodiments of the system 1000, one or more of the multiplemachines used for performing rig operations may be supported by thepressure control equipment 1008. In such cases, the pressure controlequipment 1008 may be adapted to directly support drilling loadsgenerated during drilling operations, such as the loads of the drillingmachine DM1, a tubular string connected to the drilling machine,equipment connected to the tubular string, and the like. In otherembodiments of the present disclosure, any one or all of the multiplemachines used for performing rig operations may be supported by aseparate frame 1008 f, such as a blowout preventer frame and the like,that may be disposed adjacent to or around the pressure controlequipment 1008, in which case the drilling loads generated duringdrilling operations as noted previously would be supported directly bythe frame 1008 f. Furthermore, as previously described with respect toFIG. 15 above, in at least some illustrative embodiments of the presentdisclosure, the frame 1008 f, such as a blowout preventer frame, may beat least partially supported off of one or more components of thepressure control equipment 1008, such as, for example, the blowoutpreventer apparatus, the wellhead 1008 w, and the like.

In one embodiment disclosed herein, the system 1000 may comprise one ormore tubular holders 1020 for staging the tubulars during rigoperations, and a one or more tubular movement apparatuses 1010. In someembodiments, the tubular movement apparatus 1010 may include a catwalk1025, trough 1034, v-door 1035, and other linkages that aid in thefunction of the tubular movement apparatus 1010. As shown in FIG. 21A,in some embodiments the tubular holders 1020 may be winged, that may be,placed to either side of the catwalk 1025 and trough 1034. In otherembodiments, the tubular holders may be located within a frame structure1020 f to save space.

The catwalk 1025 assists with the staging of the tubulars when manualintervention is required. In operation, once the tubulars are positionedwithin the trough 1034, the trough 1034 transports the tubulars from thetubular holder side 1101 to the wellbore location side 1100 of the rigstructure 1102 with the assistance of the v-door 1035 and associatedlinkages. The v-door 1035 assists in guiding and providing structuralsupport for the movement of the trough 1034. The movement of the trough1034) is enabled with systems such as, for example, hydraulic pistons,other alternatives in the form of pneumatic pistons, linkages, gears,chains, and the like. With the trough 1034 located within the rig floor1004 working area, it is more convenient to pick up and move thetubulars from the trough 1034 to the rig floor 1004 and vice-versa. Insome illustrative embodiments, the arms from the drilling machine DM1 orthe tripping machine TM1 may be used to facilitate transport of thetubulars.

FIG. 21D illustrates yet another illustrative embodiment of the presentdisclosure. In order to conserve valuable space on the tubular holderside 1101 of the rig structure 1002, the catwalk 1025 may be disposedabove the tubular holder 1020 on the frame 1020 f that is disposedaround the tubular holder 1020. It should be appreciated that othervariations of the tubular movement apparatus may also be used. In thisembodiment, the tubulars may be loaded from the tubular holder 1020 ontothe trough 1034 by a suitable tubular dispensing mechanism, as is wellknown in the art.

In some applications of rig operations, a need exists to conserve spaceand reduce the footprint of the rig periphery when viewed from above.Accordingly, in certain embodiments disclosed herein, the hydraulicpower unit 1018 may be elevated by a considerable distance above thebase of the rig structure 1002. In this embodiment, the trough 1034 maybe adapted to pass from within the rig structure 1002 and under thehydraulic power unit 1018. It may be appreciated that additionalvariations for tubular transportation may be used, such as lowering thehydraulic power unit 1018 and transporting the tubulars over thehydraulic power unit (1018). It may further be appreciated that, incertain other embodiments, the tubulars may similarly be passed fromeither under or over the electric power unit 1019 instead of thehydraulic power unit 1018.

Similar to the embodiments of system 600 as shown in FIGS. 15 and 15D,the multi-function rig system 1000 may be configured with a crane 1030disposed on the floor 1004. In some illustrative embodiments, the rigfloor 604 may comprise rail 1004 r (like the rails 604 r of system 600)adapted to facilitate the movement of equipment and other apparatusalong the length of the rig structure 1002. In certain embodiments thecrane 1030 may be disposed on the rails 1004 r, and may comprise a base1030 b with roller apparatuses 1032 adapted to engage with and move onthe rails 1004 r.

The particular embodiments disclosed above are illustrative only, as theinvention may be modified and practiced in different but equivalentmanners readily apparent to those skilled in the art and having thebenefit of the teachings herein. For example, the process steps setforth above may be performed in a different order. Furthermore, nolimitations are intended to the details of construction or design hereinshown, other than as described in the claims below. It is thereforeevident that the particular embodiments disclosed above may be alteredor modified and all such variations are considered within the scope andspirit of the invention. Accordingly, the protection sought herein is asset forth in the claims below.

1.-58. (canceled)
 59. A system, comprising: at least one first pressurecontrol device positioned proximate a first wellbore location, said atleast one first pressure control device being adapted to retain wellborepressure at said first wellbore location; a first machine positionedproximate said at least one first pressure control device, said firstmachine being adapted to perform a first rig operation on said firstwellbore location; and a first structural support that is adapted totransfer loads generated by said first machine during said first rigoperation to said at least one first pressure control device, whereinsaid at least one first pressure control device is adapted to supportsaid loads.
 60. The system of claim 59, wherein said first structuralsupport is attached to said at least one first pressure control deviceand said first machine is adapted to be removably coupled to said firststructural support.
 61. The system of claim 59, wherein said firstmachine is a drilling machine and said loads are drilling loads.
 62. Thesystem of claim 59, wherein said first structural support comprises aframe structure, said frame structure being attached to said at leastone first pressure control device.
 63. The system of claim 62, whereinsaid frame structure is adapted to support said loads.
 64. The system ofclaim 63, wherein said first machine is adapted to be removably coupledto said frame structure.
 65. The system of claim 59, further comprisinga rig structure, wherein said first machine is operatively coupled tosaid rig structure.
 66. The system of claim 59, further comprising atubular erector apparatus positioned proximate said first wellborelocation, wherein said tubular erector apparatus is adapted to handletubulars during said first rig operation.
 67. The system of claim 59,wherein said at least one first pressure control device comprises atleast one of a wellhead, a blowout preventer apparatus, a flowlineapparatus and a diverter apparatus.
 68. The system of claim 59, furthercomprising: at least one second pressure control device positionedproximate a second wellbore location, said at least one second pressurecontrol device being adapted to retain wellbore pressure at said secondwellbore location; a second machine positioned proximate said at leastone second pressure control device, said second machine being adapted toperform a second rig operation on said second wellbore location; and asecond structural support that is adapted to transfer loads generated bysaid second machine during said second rig operation to said at leastone second pressure control device, wherein said at least one secondpressure control device is adapted to support said loads generatedduring said second rig operation.
 69. The system of claim 67, whereinsaid second machine is one of a drilling machine, a tripping machine, acasing machine, a cementing machine, and a coiled tubing machine.
 70. Asystem, comprising: at least one pressure control device positionedproximate a wellbore location, said at least one pressure control devicebeing adapted to retain wellbore pressure at said wellbore location; aframe structure supported by said at least one pressure control device;and a drilling machine positioned proximate said wellbore location,wherein said drilling machine is adapted to perform a drilling operationon said wellbore location, and wherein said frame structure is adaptedto support drilling loads generated by said drilling machine during saiddrilling operation.
 71. The system of claim 70, wherein said drillingmachine is adapted to be removably coupled to said frame structure. 72.The system of claim 70, wherein said at least one pressure controldevice comprises a wellhead and a blowout preventer apparatus, andwherein said frame structure is a blowout preventer frame structure. 73.The system of claim 70, wherein said at least one pressure controldevice is positioned over said wellbore location and said drillingmachine is positioned over said at least one pressure control device.74. A system, comprising: a drilling machine positioned proximate awellbore location, said drilling machine being adapted to perform adrilling operation on said wellbore location; a wellhead positionedabove said wellbore location, said wellhead being adapted to retainwellbore pressure at said wellbore location and to support drillingloads generated by said drilling machine during said drilling operation;and a blowout preventer apparatus positioned above said wellhead, saidblowout preventer apparatus being adapted retain said wellbore pressure,to support said drilling loads, and to transfer said drilling loads tosaid wellhead.
 75. A method, comprising: positioning at least onepressure control device proximate a wellbore location; positioning amachine proximate said at least one pressure control device; performinga rig operation on said wellbore location with said machine; andsupporting loads generated by said machine during said rig operationwith said at least one pressure control device.
 76. The method of claim75, wherein positioning said machine proximate said at least onepressure control device comprises removably coupling said machine tosaid at least one pressure control device.
 77. The method of claim 75,further comprising attaching a frame structure to said at least onepressure control device and supporting said loads with said framestructure.
 78. The method of claim 77, further comprising removablycoupling said machine to said frame structure during said rig operation.79. The method of claim 77, further comprising positioning a rigstructure proximate said wellbore location and operatively coupling saidmachine to said rig structure during said rig operation.
 80. The methodof claim 75, wherein positioning said at least one pressure controldevice comprises positioning a blowout preventer apparatus above awellhead, wherein positioning said machine comprises positioning adrilling machine above said blowout preventer apparatus, and whereinsupporting said loads comprises supporting drilling loads generated bysaid drilling machine during a drilling operation with a blowoutpreventer frame structure that is attached at least to said wellhead.81. A method, comprising: positioning a wellhead above a wellborelocation; positioning a blowout preventer apparatus above said wellhead;positioning a drilling machine proximate said wellbore location;performing a drilling operation on said wellbore location with saiddrilling machine; supporting loads generated by said drilling machineduring said drilling operation with said wellhead, wherein supportingsaid loads comprises transferring said loads from said drilling machineto said blowout preventer apparatus; and transferring said loads fromsaid blowout preventer apparatus to said wellhead.